US5074359A - Method for hydraulic fracturing cased wellbores - Google Patents
Method for hydraulic fracturing cased wellbores Download PDFInfo
- Publication number
- US5074359A US5074359A US07/596,633 US59663390A US5074359A US 5074359 A US5074359 A US 5074359A US 59663390 A US59663390 A US 59663390A US 5074359 A US5074359 A US 5074359A
- Authority
- US
- United States
- Prior art keywords
- fracture
- wellbore
- proppant
- formation
- fluid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 238000000034 method Methods 0.000 title claims abstract description 30
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 58
- 239000012530 fluid Substances 0.000 claims abstract description 43
- 230000000977 initiatory effect Effects 0.000 claims abstract description 12
- 238000005086 pumping Methods 0.000 claims description 19
- 238000011065 in-situ storage Methods 0.000 claims description 17
- 238000002347 injection Methods 0.000 claims description 13
- 239000007924 injection Substances 0.000 claims description 13
- 239000007788 liquid Substances 0.000 claims 8
- 238000005755 formation reaction Methods 0.000 abstract description 36
- 230000000644 propagated effect Effects 0.000 abstract 1
- 238000010586 diagram Methods 0.000 description 6
- 238000011161 development Methods 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000012856 packing Methods 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 229920002261 Corn starch Polymers 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 229910001570 bauxite Inorganic materials 0.000 description 1
- 239000010620 bay oil Substances 0.000 description 1
- 239000008120 corn starch Substances 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 230000001902 propagating effect Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 238000010561 standard procedure Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/02—Determining slope or direction
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/006—Measuring wall stresses in the borehole
Definitions
- the present invention pertains to a method for hydraulically fracturing an earth formation from an inclined or deviated wellbore to improve the conductivity of the fracture.
- the overall fracture length and direction of propagation can be easily controlled.
- the wellbore casing may be perforated along a line which lies in a plane which is normal to the direction of the minimum stress.
- the injection of fluids through the perforations will initiate a series of fractures which will eventually link up and become a single vertically extending fracture, generally in a plane normal to the minimum stress.
- the near wellbore formation stresses tend to reduce the fracture dimensions and the fracture does not grow in length or height until it has turned to lie in the plane which is normal to the direction of the minimum principal stress.
- the plane of the fracture will still undergo some degree of turning as it grows in the vertical direction. Accordingly, the fracture in the near wellbore region is of smaller cross-sectional area, may be subject to relatively high closing stress and may form a point of throttling or choking of the flow of fluids between the formation and the wellbore.
- the present invention is directed to an improved method of completing a fracturing operation in a subterranean formation where such fracturing is carried out primarily from deviated or inclined wellbores and which operation overcomes some of the problems associated with prior art efforts to fracture formations from inclined wellbores.
- the present invention pertains to an improved method for fracturing subterranean formations wherein such fractures extend from so-called deviated or inclined wellbores.
- the region of the earth formation is determined which will, at the wellbore wall, provide the maximum tensile stress to be exerted on the formation during a fracturing operation. Then the fracture is initiated in a direction which corresponds to the point of maximum tensile stress and the fracture is propped open by a progressive treatment process which prevents reclosing of the fracture, particularly in a zone adjacent the wellbore and corresponding to the zone of maximum stress.
- the location of the maximum tensile stress in the formation to be seen during fracture initiation is determined using an improved method of referencing the particular point on the wellbore with respect to the highest point on the wellbore at which a perforation is to be provided, in the case of cased wellbores.
- Such particular point will provide for initiation of a fracture which will turn at the lowest rate into the vertical fracture plane which is perpendicular to the minimum in situ horizontal stress, thereby providing a propped region which is less likely to forcibly reclose than in fractures which are initiated in more highly stressed regions of the wellbore.
- This fracturing technique coupled with the injection of proppant materials in such a way that the fracture will screen out at the outer reaches of the fracture with respect to the wellbore assures that the fracture will not reclose in a region directly adjacent the wellbore.
- FIG. 1 is a schematic diagram illustrating the growth of a hydraulic fracture from a deviated or inclined wellbore and in relation to the direction of the principal stresses in the formation region being fractured;
- FIG. 2 is a view of a portion of the diagram of FIG. 1 taken along the line 2--2 of FIG. 1;
- FIG. 3 is a schematic diagram illustrating the turning of a hydraulic fracture from a vertically extending wellbore into the plane normal to the minimum in situ horizontal stress as a function of the hydraulic pumping pressure;
- FIG. 4 is a schematic diagram illustrating a transformed coordinate system for determining the point at which a fracture should occur from a deviated well and in relation to the directions of the in situ compressive stresses in the formation;
- FIG. 5 is a planar development of a fracture formed in accordance with the present invention.
- FIG. 1 there is illustrated a schematic diagram of an inclined or deviated wellbore generally designated by the numeral 12.
- the wellbore 12 is illustrated as penetrating an earth formation at an angle b with respect to the vertical and with respect to the tensor of a compressive stress s 3 comprising the principal vertical stress due to the weight of the earth, primarily.
- the compressive stresses may be resolved into the vertical stress s 3 and principal horizontal compressive stresses comprising a maximum stress s 2 and a minimum stress s 1 .
- the wellbore 12 is shown inclined at the angle b with respect to the direction of the vertical compressive stress s 3 and at an angle a with respect to the direction of the minimum principal horizontal compressive stress s 1 .
- the minimum compressive stress may be other than a generally horizontal stress.
- the wellbore may also be "inclined" with respect to the formation region of interest but extended in a vertical direction.
- the wellbore 12 is indicated to have had initiated a fracture in the region 14 which propagates outward while seeking to extend itself in a plane which is normal to the direction of the horizontal stress s 1 . Accordingly, the fracture initially propagates away from the wellbore at 14 and undergoes a turning effort to develop a curved portion 16 and eventually a somewhat planar, vertical portion 18 which is generally normal to the direction of the stress s 1 .
- FIG. 2 illustrates the final directions of extension of the fracture portion 18 such as at 20 and 22.
- the wellbore 12 is shown having a casing 13 with perforations 15 and 17 formed therein.
- the direction of the minimum in situ compressive stress s 1 is also indicated in FIG. 3.
- the wellbore 12 is shown having a casing 13 with perforations 15 and 17 formed therein.
- the direction of the minimum in situ compressive stress s 1 is also indicated in FIG. 3.
- the respective directions of fracture propagation are enhanced by high hydraulic pumping pressure so that the single fracture emanating from the perforation 17 initially extends somewhat radially outwardly from the perforation 17 and then begins its turn into the plane which is normal to the minimum in situ stress as indicated by the fracture 36, for example.
- the fracture will migrate away from the perforations but immediately turn to seek the region of the formation which will break down first.
- This configuration of fracture may not be conducive to the flow of fluids therethrough and not be amenable to being easily kept open by the placement of a proppant in the fracture.
- such deviated fractures if not propped open in accordance with the present invention, will tend to close at the point directly adjacent the wellbore perforations and squeeze any fluid or proppant in that portion of the fracture into the main body of the fracture. Accordingly, the fracture will be pinched off from communicating with the wellbore and will be devoid of proppant in the region of the fracture directly adjacent the wellbore.
- the problem then becomes one of determining the proper placement of perforations in a cased wellbore for initiation and propagation of a hydraulic fracture when the wellbore is inclined or deviated from the vertical.
- the orientation of the in situ stresses may be determined from known techniques such as the study of fault maps from previous exploration activity, extracting core samples from the formation region of interest, preferably through the wellbore, or by other measurement techniques including instruments that may be placed in the wellbore in the region of interest before the wellbore is cased.
- the so-called "high" side of the wellbore should be referenced since this position may be easily determined by wellbore orientation instruments.
- FIG. 4 is a diagram indicating the coordinate system which is used in developing the equations in the aforementioned publication, and in particular, the equation for the maximum tensile stress in the formation surrounding the wellbore at the point of interest as a function of the angle t which is measured from the transformed coordinate system illustrated in FIG. 4, that is the x, y, z coordinate system wherein the z axis is the wellbore axis, the x axis is an axis normal to the wellbore axis and passing through the highest point on the surface of the wellbore at any given position along the wellbore and indicated by the numeral 40 in FIG. 4.
- the angle t is the angle of the maximum tensile stress that will be experienced in the formation in the region to be perforated with respect to the x axis and the maximum tensile stress, s m , as a function of the angle t, may be expressed by the following equation: ##EQU1## where s z equals the normal stress parallel to the wellbore axis at the wellbore surface,
- s t equals the circumferential (hoop) stress around the wellbore surface
- s tz equals the shearing stress in the surface of the wellbore.
- the angular orientation (t o ) of the initial fracture is determined by differentiating equation (1) with respect to t, viz., ##EQU2##
- the stresses in the coordinate system of the wellbore may be determined from the equations set forth in the aforementioned publication based on actual measurement of core samples, sonic logs, data fracs, or other standard techniques.
- the wellbore 12 may be perforated at the angle t o with respect to the x axis, which axis passes through the highest point on the wellbore and thus makes it relatively easy to orient the perforating gun. Fracture operations may then be carried out in a manner which, in accordance with the present invention, minimizes the possibility of the fracture closing in the area adjacent the wellbore and which area is subject to high stresses and tends to pinch off or close and squeeze proppant from that region into the main body of the fracture if the fracture has not been properly prepared.
- a well is drilled into a producible formation such as the Prudhoe Bay Oil Field, Alaska, to a depth of approximately 10,000 feet with the wellbore forming an angle to the vertical in the region of interest of approximately 34°.
- the formation region of interest is cased with a 5 1/2 inch production liner.
- In situ stress measurements indicate that the optimum angle t for placement of the casing perforations is approximately 30° counter-clockwise from the "high side" of the wellbore looking top to bottom. This angle is selected by making the calculations referenced in equations 1 and 2 and from the procedure described in SPE Publication No. 19722.
- An initial injection rate is prescribed of 40 barrels per minute for a so-called pre-pad stage and which develops a relatively large radius of curvature near the wellbore.
- a "slick water" fluid is chosen to reduce pressure drop down the wellbore tubing and resulting in the highest possible injection rate.
- the large radius of curvature of the initial portion 16 of the fracture aids in minimizing the loss of fracture conductivity near the wellbore as a result of the initial fracture plane realigning itself normal to the minimum in situ horizontal stress.
- the higher radius of curvature also reduces pressure losses during treatment.
- a total of 80 barrels is pumped during the so-called pre-pad pumping stage.
- the pre-pad treatment is followed by an injection of approximately 270 barrels of clean fluid without proppant to open the main body of the fracture such as the portion 18, 20, 22 referenced in FIG. 1.
- This fluid may include a mixture of 100 mesh corn starch or other fluid loss additives to provide a total volume of approximately 320 barrels.
- the pad injection is followed by the injection of first stage of proppant comprising a quantity of approximately 50 barrels of fracturing fluid laden with a total of 2000 pounds of proppant.
- the proppant is preferably an intermediate strength, bauxite type sold under the trademark INTERPROP and is injected together with the fluid in a slurry at a rate of approximately 20 barrels per minute.
- This stage is followed by the injection of a second stage of proppant-laden fracturing fluid in the amount of about 50 barrels of fluid having a quantity of about 3800 pounds of proppant mixed therein and pumped at a rate of approximately 15 barrels per minute.
- Successive stages of 100 barrels of fluid are pumped each having quantities of about 14,000 pounds of proppant and 19,000 pounds of proppant, respectively, and wherein both stages are pumped at a rate of 15 barrels per minute.
- a final stage of approximately 400 barrels of proppant-laden fluid is pumped having approximately 99,000 pounds of proppant mixed into 296 barrels of clean fluid and pumped at a rate of 15 barrels per minute.
- FIG. 5 illustrates the proppant injection or staging as indicated by the dashed lines 42, 44, 46, 48 and 50.
- the regions of the fracture between the lines 42, 44, 46, 48 and 50 will eventually become densely packed with proppant as a result of fluid leak-off into the formation.
- the fracture has been developed into a planar arrangement for convenience of viewing although the fracture might take a course similar to that illustrated in FIG. 1 for a single wing fracture.
- the opposite wing of the fracture is not illustrated in FIGS. 1 or 5 in the interest of clarity and conciseness.
- the aforementioned procedure provides a fracture which is packed or screened out and which minimizes the portion of the fracture in which width reduction will occur by progressively increasing the proppant density per unit volume of pumped fluid in successive stages of injection of the fracture fluid in a deviated wellbore fracture of the type described herein. If the near wellbore stresses tend to force the proppant-laden fluid into the main body of the fracture, this action will be retarded and the region of the fracture adjacent the wellbore will remain suitably propped open.
- the above-mentioned fracture was carried out with a fluid of the delayed cross-linked water-based type.
Abstract
Description
Claims (9)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US07/596,633 US5074359A (en) | 1989-11-06 | 1990-10-10 | Method for hydraulic fracturing cased wellbores |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US43266089A | 1989-11-06 | 1989-11-06 | |
US07/596,633 US5074359A (en) | 1989-11-06 | 1990-10-10 | Method for hydraulic fracturing cased wellbores |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US43266089A Continuation | 1989-11-06 | 1989-11-06 |
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US5074359A true US5074359A (en) | 1991-12-24 |
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US07/596,633 Expired - Lifetime US5074359A (en) | 1989-11-06 | 1990-10-10 | Method for hydraulic fracturing cased wellbores |
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